Method and system for efficient nonsynchronous LNG production using large scale multi-shaft gas turbines

ABSTRACT

A drive system for liquefied natural gas (LNG) refrigeration compressors in a LNG liquefaction plant. Each of three refrigeration compression strings include refrigeration compressors and a multi-shaft gas turbine capable of non-synchronous operation. The multi-shaft gas turbine is operationally connected to the refrigeration compressors and is configured to drive the one or more refrigeration compressors. The multi-shaft gas turbine uses its inherent speed turndown range to start the one or more refrigeration compressors from rest, bring the one or more refrigeration compressors up to an operating rotational speed, and adjust compressor operating points to maximize efficiency of the one or more refrigeration compressors, without assistance from electrical motors with drive-through capability and variable frequency drives.

CROSS REFERENCE TO RELATED APPLICATIONS

This application is a continuation and claims priority to applicationSer. No. 15/934,292, filed Mar. 23, 2018, which claims the prioritybenefit of both U.S. Patent Application No. 62/506,922 filed May 16,2017 entitled METHOD AND SYSTEM FOR EFFICIENT NONSYNCHRONOUS LNGPRODUCTION USING LARGE SCALE MULTI-SHAFT GAS TURBINES, and U.S. PatentApplication No. 62/570,998 filed Oct. 11, 2017 entitled METHOD ANDSYSTEM FOR EFFICIENT NONSYNCHRONOUS LNG PRODUCTION USING LARGE SCALEMULTI-SHAFT GAS TURBINES, the entirety of both being incorporated byreference herein.

FIELD

The present techniques provide methods and systems for producingliquefied natural gas (LNG). More specifically, the present techniquesprovide for methods and systems to produce LNG using large-scalemulti-shaft gas turbines.

BACKGROUND

This section is intended to introduce various aspects of the art, whichcan be associated with exemplary examples of the present techniques.This description is believed to assist in providing a framework tofacilitate a better understanding of particular aspects of the presenttechniques. Accordingly, it should be understood that this sectionshould be read in this light, and not necessarily as admissions of priorart.

Liquefied natural gas (LNG) is produced by cooling natural gas usingprocesses that generally require refrigeration compressors andcompressor drivers. Liquefying natural gas enables monetization ofnatural gas resources, and the meeting of energy demands, in areas wherepipeline transport of natural gas is cost prohibitive. In a typical LNGrefrigeration configuration, illustrated in FIG. 1 , a common driveshaft 102 connects a gas turbine 104 to one end of a compressor 106. Thecommon drive shaft 102 also connects a starter motor 108 to the otherend of the compressor 106. The three connected devices are typicallyreferred to as a compression string 100. Multiple, collocatedcompression strings may be referred to as an LNG train.

Global LNG competition has intensified, with potential growth from newprojects in development currently being forecast to outstrip new firmdemand. To enhance the profitability of future LNG projects there is aneed to identify and optimize the key cost drivers and efficienciesapplicable to each project.

When a large scale resource is available, developing it with a smallnumber of large capacity LNG trains can provide environmental benefits(such as minimizing the overall footprint of the constructed facilities)and economic benefits (such as accelerating the production profiles).Further, minimizing the number of compression strings installed in eachLNG train can provide an avenue to reduce the capital cost required todevelop the resource.

Many LNG trains currently in operation worldwide with capacitiesexceeding 5 MTA (million tons per annum) use the AP-C3MR™ or AP-X®process technologies licensed by Air Products and Chemicals, Inc. withrefrigerant compressors driven by two to three large scale single shaftGE Frame 7E or GE Frame 9E industrial gas turbines. Other similarlysized LNG trains with capacities exceeding 5 MTA use the OptimizedCascade® process, owned by ConocoPhillips, with refrigerant compressorsdriven either by eight small scale two-shaft GE Frame 5D gas turbines orfour single shaft GE Frame 6 and GE Frame 7 single shaft gas turbines.

Rasmussen (U.S. Pat. No. 7,526,926) explains that single shaftindustrial gas turbines typically require a large electric startingmotor to spin the turbine and compressor up to operating speed. To avoidshocking the drive train during start-up, a variable frequency drive isused to gradually increase the speed of the rotating shaft from 0 rpm upto 3,000 rpm (50 Hz), 3,600 rpm (60 Hz) or other target operating speed.The starter motor can function as a helper motor to supplement turbineoutput during normal operation and achieve LNG train capacities higherthan throughput supported by gas turbine power alone. During normaloperation the variable frequency drive can modulate the shaft speed totake advantage of the modest turndown range available to single-shaftgas turbines (on order of +/− 5%) to improve operating efficiency of therefrigerant compressors.

FIG. 2 is a schematic diagram of an exemplary LNG train 200 havingfirst, second, and third compression strings 202, 204, 206 according toknown principles. Each compression string includes a single shaft 212,214, 216 and is driven by a single-shaft gas turbine 222, 224, 226,which in some cases may be a GE Frame 9E single-shaft gas turbine. Eachcompression string also includes one or more refrigeration compressors232, 234, 235, 236. Each compression string further includes alarge-scale variable frequency drive (VFD) 242, 244, 246 and amotor/generator 252, 254, 256. Such an LNG train may have a nominal LNGproduction capacity of 8 MTA. It has been observed that the compressionpower required by different strings operating in the same train isgenerally different, likely resulting in a gas turbine power useimbalance when the compression strings are driven by identical gasturbines. This creates an opportunity to export excess gas turbine powerfrom one compression string to the plant electric power grid and toreallocate some or all of this excess power to supplement power drivingone or more of the other compressor strings.

FIG. 3 depicts another known type of compression string 300, in which anelectric starter/helper motor/generator 302 with drive-throughcapability, is positioned between a turbine 304 and a compressor 306 ona common drive shaft 308, and a variable frequency drive (VFD) 310electrically connected between the electric starter/helpermotor/generator 302 and an electrical power grid 312. The VFD 310conditions the AC frequency both from the electrical power grid 312 forsmoother startup and nonsynchronous helper duty as well as to theelectrical power grid, such that mechanical power can be converted toelectrical power by the electric starter/helper orator/generator 302 andsupplied to the electrical power grid at the grid frequency. This allowsthe speed of the turbine 304 to be dictated by throughput needs. Thiscompression string 300, as disclosed by Rasmussen, enables LNG trainconfigurations with single shaft gas turbines, such as LNG train 200, tomaximize capacity by shifting excess gas turbine power to power limitedcompressor strings, and maximize fuel efficiency by operating all gasturbines at or near peak load. When used in an LNG train, compressionstring 300 permits nonsynchronous operation with each individualcompression string and the electrical grid potentially at differentoperating speeds and frequencies, and for efficient gas turbineoperation with speed control, thereby providing for LNG throughputcontrol, compressor operating point optimization, and greater resilienceto process upsets compared to known synchronous LNG train operation withsingle-shaft turbines at fixed speeds, as disclosed, for example, inU.S. Pat. No. 5,689,141 by Kikkawa.

Aeroderivatives are smaller scale multi-shaft turbines that do notrequire a large electrical motor for starting the compression strings,providing some cost benefits by eliminating the large electrical motors,variable frequency drives, and power generation capacity required bylarge scale single-shaft gas turbines. A larger number ofaeroderivatives is required than large scale industrial turbines inorder to achieve similar LNG train capacities due to the lower poweroutput of the aeroderivative units, potentially increasing the overallcost of a large scale development. On the other hand, new multi-shaftgas turbine options are becoming available, including fuel efficientlarge scale multi-shaft industrial turbines such as the GE LMS100, theMitsubishi Hitachi H110 and the Siemens SGT5-2000E turbines, and some ofthese large multi-shaft gas turbines operate at lower speeds compared tosmaller turbines, thereby permitting more aerodynamically efficientlarge compressors that may be used in LNG service. What is thereforeneeded is an LNG compression string design and/or LNG train design thatuses new turbine technology to support large-scale (i.e., >5 MTA) LNGproduction. What is also needed is such a large-scale LNG compressionstring design and/or LNG train design with a reduced amount ofcomponents contained therein.

SUMMARY

The disclosed aspects provide a drive system for liquefied natural gas(LNG) refrigeration compressors in a LNG liquefaction plant. First,second, and third refrigeration compression strings each include one ormore refrigeration compressors, and a multi-shaft gas turbine capable ofnon-synthronous operation, the multi-shaft gas turbine beingoperationally connected to the one or more refrigeration compressors andconfigured to drive the one or more refrigeration compressors, whereinthe multi-shaft gas turbine uses its inherent speed turndown range tostart the one or more refrigeration compressors from rest, bring the oneor more refrigeration compressors up to an operating rotational speed,and adjust compressor operating points to maximize efficiency of the oneor more refrigeration compressors, without assistance from electricalmotors with drive-through capability and variable frequency drives. Thefirst refrigeration compression string is configured to providecompression to a propane refrigerant, the second refrigerationcompression string is configured to provide compression to a mixed,refrigerant, and the third refrigeration compression string isconfigured to provide compression to a nitrogen refrigerant.

The disclosed aspects also provide a method of producing liquefiednatural gas (LNG). Each of first, second, and third refrigerationcompression strings are arranged to include one or more refrigerationcompressors and a multi-shaft gas turbine operationally connected to theone or more refrigeration compressors. The multi-shaft gas turbine ineach of the first, second, and third refrigeration compression stringsis used to drive the respective one or more refrigeration compressorsusing a non-synchronous operation. Compression to a propane refrigerantis provided using the first refrigeration compression string.Compression to a mixed refrigerant is provided using the secondrefrigeration compression string. Compression to a nitrogen refrigerantis provided using the third refrigeration compression string, Withoutassistance from electrical motors with drive-through capability orvariable frequency drives, using an inherent speed turn-down range of atleast one of the multi-shaft gas turbines of the first, second, andthird refrigeration compression strings to start the one or morerefrigeration compressors from rest, bring the one or more refrigerationcompressors up to an operating rotational speed, and adjust compressoroperating points to maximize efficiency of the one or more refrigerationcompressors.

DESCRIPTION OF THE DRAWINGS

The advantages of the present techniques are better understood byreferring to the following detailed description and the attacheddrawings, in which:

FIG. 1 is a schematic diagram of an LNG compression string according toknown principles;

FIG. 2 is a schematic diagram of an LNG train according to knownprinciples;

FIG. 3 is a schematic diagram of an LNG compression string according toknown principles;

FIG. 4 is a schematic diagram of an LNG train according to disclosedaspects;

FIG. 5 is a schematic diagram of an LNG liquefaction system that may beused with the disclosed aspects;

FIG. 6 is a schematic diagram of a detail of FIG. 5 ;

FIG. 7 is a schematic diagram of an LNG refrigeration compression stringaccording to disclosed aspects;

FIG. 8 is a schematic diagram of an LNG refrigeration compression stringaccording to disclosed aspects;

FIG. 9 is a schematic diagram of an LNG refrigeration compression stringaccording to disclosed aspects; and

FIG. 10 is a flowchart of a method according to disclosed aspects.

DETAILED DESCRIPTION

In the following detailed description section, non-limiting examples ofthe present techniques are described. However, to the extent that thefollowing description is specific to a particular example or aparticular use of the present techniques, this is intended to be forexemplary purposes only and simply provides a description of theexemplary examples. Accordingly, the techniques are not limited to thespecific examples described below, but rather, include all alternatives,modifications, and equivalents falling within the true spirit and scopeof the appended claims.

At the outset, for ease of reference, certain terms used in thisapplication and their meanings as used in this context are set forth.Further, the present techniques are not limited by the usage of theterms shown below, as all equivalents, synonyms, new developments, andterms or techniques that serve the same or a similar purpose areconsidered to be within the scope of the present claims.

As one of ordinary skill would appreciate, different persons may referto the same feature or component by different names. This document doesnot intend to distinguish between components or features that differ inname only. The figures are not necessarily to scale. Certain featuresand components herein may be shown exaggerated in scale or in schematicform and some details of conventional elements may not be shown in theinterest of clarity and conciseness. When referring to the figuresdescribed herein, the same reference numerals may be referenced inmultiple figures for the sake of simplicity. In the followingdescription and in the claims, the terms “including” and “comprising”are used in an open-ended fashion, and thus, should be interpreted tomean “including, but not limited to.”

The articles “the,” “a” and “an” are not necessarily limited to meanonly one, but rather are inclusive, and open ended so as to include,optionally, multiple such elements.

As used herein, the terms “approximately,” “about,” “substantially,” andsimilar terms are intended to have a broad meaning in harmony with thecommon and accepted usage by those of ordinary skill in the art to whichthe subject matter of this disclosure pertains. It should be understoodby those of skill in the art who review this disclosure that these termsare intended to allow a description of certain features described andclaimed without restricting the scope of these features to the precisenumeral ranges provided. Accordingly, these terms should be interpretedas indicating that insubstantial or inconsequential modifications oralterations of the subject matter described and are considered to bewithin the scope of the disclosure.

“Exemplary” is used exclusively herein to mean “serving as an example,instance, or illustration.” Any embodiment or aspect described herein as“exemplary” is not to be construed as preferred or advantageous overother embodiments.

The term “gas” is used interchangeably with “vapor,” and is defined as asubstance or mixture of substances in the gaseous state as distinguishedfrom the liquid or solid state. Likewise, the term “liquid” means asubstance or mixture of substances in the liquid state as distinguishedfrom the gas or solid state.

A “hydrocarbon” is an organic compound that primarily includes theelements hydrogen and carbon, although nitrogen, sulfur, oxygen, metals,or any number of other elements can be present in small amounts. As usedherein, hydrocarbons generally refer to components found in natural gas,oil, or chemical processing facilities.

“Natural gas” refers to a multi-component gas obtained from a crude oilwell or from a subterranean gas-bearing formation. The composition andpressure of natural gas can vary significantly. A typical natural gasstream contains methane (CH₄) as a major component, i.e., greater than50 mol % of the natural gas stream is methane. The natural gas streamcan also contain ethane (C₂H₆), heavy hydrocarbons (e.g., C₃-C₂₀hydrocarbons), one or more acid gases (e.g., CO₂ or H₂S), or anycombinations thereof. The natural gas can also contain minor amounts ofcontaminants such as water, nitrogen, iron sulfide, wax, crude oil, orany combinations thereof. The natural gas stream can be substantiallypurified, so as to remove compounds that may act as poisons.

“Liquefied Natural Gas” or “LNG” refers to is natural gas that has beenprocessed to remove one or more components (for instance, helium) orimpurities (for instance, water and/or heavy hydrocarbons) and thencondensed into a liquid at almost atmospheric pressure by cooling.

A “Large Scale” gas turbine is a gas turbine having a rated outputcapacity of at least 70 megawatts (MW), or at least 80 MW, or at least100 MW.

A “mixed refrigerant” is refrigerant formed from a mixture of two ormore components selected from the group comprising: nitrogen, methane,ethane, ethylene, propane, propylene, butanes, pentanes, etc. A mixedrefrigerant or a mixed refrigerant stream as referred to hereincomprises at least 5 mol % of two different components. A commoncomposition for a mixed refrigerant can be: Nitrogen 0-10 mol %; Methane(C₁) 30-70 mol %; Ethane (C₂) 30-70 mol %; Propane (C₃) 0-30 mol %;Butanes (C₄) 0-15 mol %. The total composition comprises 100 mol %.

“Substantial” when used in reference to a quantity or amount of amaterial, or a specific characteristic thereof, refers to an amount thatis sufficient to provide an effect that the material or characteristicwas intended to provide. The exact degree of deviation allowable maydepend, in some cases, on the specific context.

“Non-synchronous” refers to rotational speeds that are not alwaysaligned with local electrical grid frequency (which may be 50 Hz (3,000rpm), 60 Hz (3,600 rpm), or another frequency) but fall within acommonly accepted operating range around the local frequency. Suchoperating range depends on the design of the turbine and may be ±3%, or±5%, or ±10%, or ±20% or more than ±20% of the local frequency.

The present techniques provide an LNG train having two or morecompression strings. Each compression string has a refrigerationcompressor that is non-synchronously driven by a large multi-shaft gasturbine. Each gas turbine is capable of starting its respectivecompressors from rest (either with refrigerant compression remaining inthe refrigeration compression loop or without such compression) and tobring the compressors up to operating rotational speed. Each gas turbineis further configured to adjust compressor operating points to maximizeefficiency using the inherent speed turndown range of the multi-shaftgas turbines. With this arrangement, electrical starter motors withdrive-through capability and variable frequency drives are not required.

FIG. 4 is a schematic diagram of an LNG train 400 according to disclosedaspects. LNG train 400 includes two or more compression strings, and ina preferred aspect includes first, second, and third compression strings402, 404, 406. First compression string 402 includes first and secondrefrigeration compressors 412, 422 connected via a first shaft 432 toone or more large-scale multi-shaft gas turbines 442. Second compressionstring 404 includes third and fourth refrigeration compressors 414, 424connected via a second shaft 434 to one or more large-scale multi-shaftgas turbines 444. Third compression string 406 includes fifth and sixthrefrigeration compressors 416, 426 connected via a third shaft 436 toone or more large-scale multi-shaft gas turbines 446. Each of the one ormore large scale multi-shaft gas turbines 442, 444, 446 provide adriving force to the refrigeration compressors associated with itsrespective compression string. In an aspect, the large scale multi-shaftgas turbines 442, 444, 446 may comprise the GE LMS100 turbine, theMitsubishi Hitachi H110 turbine, the Siemens SGT5-2000E turbine, or anyother large-scale multi-shaft gas turbine. Because the large scalemulti-shaft gas turbines can take advantage of their inherent widerturndown range than single-shaft gas turbines, LNG train production andefficiency may be improved and even maximized. For example, the inherentturn-down range of the large scale multi-shaft gas turbines may be usedto start the compressors from rest, bring the compressors up to anoperating rotational speed, and adjust the compressor operating pointsto maximise efficiency of the compressors, all without assistance fromelectrical motors with drive-through capability or variable frequencydrives. The use of large scale fuel-efficient multi-shaft gas turbinesin a configuration as shown in FIG. 4 allows for LNG train capacities inexcess of 7-8 MTA with only three refrigerant compression strings. Whilethis is a comparable output to current very large LNG trains using thesame number of compression strings, because starter and electrical powerare no longer necessary to achieve these capacities with the LNG train400, the electrical equipment such as the starter/helper motor/generator302 and the variable frequency drive 310 (FIG. 3 ) can be eliminatedfrom the refrigerant compression strings. The elimination of thesecomponents (including the removal or downsizing of some electrical powergeneration equipment otherwise required to drive the starter/helpermotors) provides significant capital cost savings as well as operatingcravings.

In an aspect, first compression string 402 may be used to providecompression for a propane refrigerant, second compression string 404 maybe used to provide compression for a mixed refrigerant, and thirdcompression string 406 may be used to provide compression for a nitrogenrefrigerant. In a further aspect, the refrigeration compressor(s) of oneor more of the first, second, and third compression strings may beconfigured to assist the compression work of the other compressionstrings by moving compression stages from said compressor to thatstring. For example, large-scale multi-shaft gas turbine 442 of thefirst compression string 402 may be used to assist in the compression ofthe mixed refrigerant by refrigeration compressors 424, 414 of thesecond compression string 404 by moving all or part of the compressionstage to first compression string 402, thereby assisting the secondcompression string 404.

In another aspect, two of the compression strings may be designed toprovide compression to the same two refrigerants. For example, first andfourth refrigeration compressors 412, 424 may be designed to providecompression to a first refrigerant, such as propane, and second andthird refrigeration compressors 422, 414, may be designed to providecompression to a second refrigerant, such as a mixed refrigerant. Withthis configuration, it may be possible to only require one of the firstand second refrigeration strings 402, 404 for natural gas liquefaction.This may be desirable when only a small amount of natural gas isavailable, or when one of the refrigeration strings is shut down formaintenance or replacement. Additionally, and when used in conjunctionwith third compression string 406, it may be possible to only require(a) one of the first and second refrigeration strings 402, 404, and (b)the third refrigeration string 406, for natural gas liquefaction. Thisscenario may be desirable when a higher LNG production rate is desired,because the nitrogen compressed by the third compression string 406would provide the additional chilling necessary to liquefy natural gaswhen only one of the first and second refrigeration strings 402, 404 arebeing used. In any event, the first and second refrigeration strings402, 404 may be configured such that the third compression string 406 isnot required for natural gas liquefaction.

The disclosed aspects may be advantageously used when operation of one,two, or all of the large scale multi-shaft turbines is required to chillthe air to be combusted in the large-scale, multi-shaft gas turbines ofthe first, second, and third refrigeration compression strings.Furthermore, the disclosed aspects may be advantageously used inliquefaction operations, such as the liquefaction of natural gas toproduce LNG.

While the wide speed range of multi-shaft gas turbines provides forthroughput control and efficient gas turbine operation, the removal ofthe starter/helper motor/generators may result in a scenario where anLNG train as shown in FIG. 4 operates with a power imbalance aspreviously described, with one compression string being power limitedwhile there is excess gas turbine power available to one or two of theother strings. This situation can be avoided or mitigated by selectingan optimal process and machinery configuration that maximizes use of thegas turbine power with consideration for characteristic variations inambient temperature and feed gas compositions. These configurationsinclude but are not limited to the AP-C3MR™ process and the AP-X®process using independent or split mixed refrigerant configurations.Refrigeration compressors can be further configured in series or inparallel to optimize gas turbine power use and overall LNG trainreliability.

In another aspect, inlet air chilling can be applied to fully use excessgas turbine power and to maximize LNG production in an LNG train. FIGS.5-6 illustrate a system 510 and process for liquefying natural gas (LNG)that uses inlet air chilling. This system and similar inlet air chillingsystems are further described in commonly owned U.S. Patent PublicationNo. 2018/0051928, filed Aug. 16, 2016, and in U.S. Pat. No. 6,324,867,the disclosures of which are incorporated by reference herein in theirentirety. In system 510, feed gas (natural gas) enters through an inletline 511 into a preparation unit 512 where it is treated to removecontaminants. The treated gas then passes from preparation unit 512through a series of heat exchangers 513, 514, 515, 516, where it iscooled by evaporating the first refrigerant (e.g. propane) which, inturn, is flowing through the respective heat exchangers through a firstrefrigeration circuit 520. The cooled natural gas then flows tofractionation column 517 wherein pentanes and heavier hydrocarbons areremoved through line 518 for further processing in a fractionating unit519.

The remaining mixture of methane, ethane, propane, and butane is removedfrom fractionation column 517 through line 521 and is liquefied in themain cryogenic heat exchanger 522 by further cooling the gas mixturewith a second refrigerant that may comprise a mixed refrigerant (MR)which flows through a second refrigerant circuit 530. The secondrefrigerant, which may include at least one of nitrogen, methane,ethane, and propane, is compressed in compressors 523 a, 523 b which, inturn, are driven by a gas turbine 524. After compression, the secondrefrigerant is cooled by passing through air or water coolers 525 a, 525b and is then partly condensed within heat exchangers 526, 527, 528, and529 by evaporating the first refrigerant from first refrigerant circuit520. The second refrigerant may then flow to a high pressure separator531, which separates the condensed liquid portion of the secondrefrigerant from the vapor portion of the second refrigerant. Thecondensed liquid and vapor portions of the second refrigerant are outputfrom the high pressure separator 531 in lines 532 and 533, respectively.As seen in FIG. 1 both the condensed liquid and vapor from high pressureseparator 531 flow through main cryogenic heat exchanger 522 where theyare cooled by evaporating the second refrigerant.

The condensed liquid stream in line 532 is removed from the middle ofmain cryogenic heat exchanger 522 and the pressure thereof is reducedacross an expansion valve 534. The now low pressure second refrigerantis then put back into the main cryogenic heat exchanger 522 where it isevaporated by the warmer second refrigerant streams and the feed gasstream in line 521. When the second refrigerant vapor stream reaches thetop of the main cryogenic heat exchanger 522, it has condensed and isremoved and expanded across an expansion valve 535 before it is returnedto the main cryogenic heat exchanger 522. As the condensed secondrefrigerant vapor falls within the main cryogenic heat exchanger 522, itis evaporated by exchanging heat with the feed gas in line 521 and thehigh pressure second refrigerant stream in line 532. The fallingcondensed second refrigerant vapor mixes with the low pressure secondrefrigerant liquid stream within the middle of the main cryogenic heatexchanger 522 and the combined stream exits the bottom of the maincryogenic heat exchanger 522 as a vapor through outlet 536 to flow backto compressors 523 a, 523 b to complete second refrigerant circuit 530.

The closed first refrigeration circuit 520 is used to cool both the feedgas and the second refrigerant before they pass through main cryogenicheat exchanger 522. The first refrigerant is compressed by a firstrefrigerant compressor 537 which, in turn, is powered by a gas turbine538. In an aspect, an additional refrigerant compressor and gas turbine(not shown), arranged in parallel with the first refrigerant compressor537 and the gas turbine 538, may be used to compress the firstrefrigerant, it being understood that reference to the first refrigerantcompressor 537 and the gas turbine 538 herein also refer to saidadditional refrigerant compressor and gas turbine. The first refrigerantcompressor 537 may comprise at least one compressor casing and the atleast one casing may collectively comprise at least two inlets toreceive at least two first refrigerant streams at different pressurelevels. The compressed first refrigerant is condensed in one or morecondensers or coolers 539 (e.g., seawater or air cooled) and iscollected in a first refrigerant surge tank 540 from which it iscascaded through the heat exchangers (propane chillers) 513, 514, 515,516, 526, 527, 528, 529 where the first refrigerant evaporates to coolboth the feed gas and the second refrigerant, respectively. Both gasturbine systems 524 and 538 may comprise air inlet systems that in turnmay comprise air filtration devices, moisture separation devices,chilling and/or heating devices or particulate separation devices.

Means may be provided in system 510 of FIG. 1 for cooling the inlet air570, 571 to both gas turbines 524 and 538 for improving the operatingefficiency of the turbines. Basically, the system may use excessrefrigeration available in system 510 to cool an intermediate fluid,which may comprise water, glycol or another heat transfer fluid, that,in turn, is circulated through a closed, inlet coolant loop 550 to coolthe inlet air to the turbines.

Referring to FIG. 2 , to provide the necessary cooling for the inlet air570, 571, a slip-stream of the first refrigerant is withdrawn from thefirst refrigeration circuit 520 (i.e. from surge tank 540) through aline 551 and is flashed across an expansion valve 552. Since firstrefrigeration circuit 520 is already available in gas liquefactionprocesses of this type, there is no need to provide a new or separatesource of cooling in the process, thereby substantially reducing thecosts of the system. The expanded first refrigerant is passed fromexpansion valve 552 and through a heat exchanger 553 before it isreturned to first refrigeration circuit 520 through a line 554. Thepropane evaporates within heat exchanger 553 to thereby lower thetemperature of the intermediate fluid Which, in turn, is pumped throughthe heat exchanger 553 from a storage tank 555 by pump 556.

The cooled intermediate fluid is then pumped through air chillers orcoolers 557, 558 positioned at the inlets for turbines 524, 538,respectively. As inlet air 570, 571 flows into the respective turbines,it passes over coils or the like in the air chillers or coolers 557, 558which, in turn, cool the inlet air 570, 571 before the air is deliveredto its respective turbine. The warmed intermediate fluid is thenreturned to storage tank 555 through line 559. Preferably, the inlet air570, 571 will be cooled to no lower than about 5° Celsius (41°Fahrenheit) since ice may form at lower temperatures. In some instances,it may be desirable to add an anti-freeze agent (e.g. ethylene glycol)with inhibitors to the intermediate fluid to prevent plugging, equipmentdamage and to control corrosion.

One aspect of the present disclosure is illustrated in detail in FIG. 6. FIG. 6 adds a wet air fin cooler 604 is connected to the firstrefrigeration circuit 520. As used with the present disclosure, wet airfin cooler 604 combines the cooling effectiveness of (a) a conventionalair fin heat exchanger, which may use a fan 608 to pass ambient air overfinned tubes through which pass the fluid (e.g., liquid or gas) to becooled to near ambient temperature (e.g. dry bulb temperature), with (b)psychometric cooling by vaporizing a liquid, typically water, within theambient air stream using, for example, nozzles 610 in a spray header612, to approach the lower wet bulb temperature of the ambient air.

Wet air fin cooler 604 is used to sub-cool the slip-stream of liquidfirst refrigerant in line 551 from surge tank 540. The sub-cooled firstrefrigerant is directed through line 605 to heat exchanger 553.Sub-cooling this propane increases both the refrigeration duty of heatexchanger 553 and the coefficient of performance of the refrigerationsystem. This coefficient of performance is the ratio of therefrigeration duty of the heat exchanger 553 divided by the incrementalcompressor power to provide that refrigeration. The wet air fin cooler604 is positioned to cool the slip-stream of first refrigerant in line551 in FIGS. 5 and 6 . Alternatively, the wet air fin cooler 604 couldbe incorporated as part of the one or more condensers or coolers 539 tosub-cool liquid propane that serves the other parts of the liquefactionprocess before the slip-stream of first refrigerant in line 551 isremoved to provide a source of cooling (direct or indirect) to airchillers or coolers 557, 558. However, it is preferred to sub-cool onlythe slip-stream of propane in line 551 to maximize the benefit withrespect to gas turbine inlet air chilling.

According to disclosed aspects, separators 601 and 602 are positioned inthe gas turbine air inlet following the air chillers or coolers 558,557, respectively. These separators 601, 602 remove the water that iscondensed from the inlet air 570, 571 as the inlet air is cooled fromits ambient dry bulb temperature to a temperature below its wet bulbtemperature. Separators 601, 602 may be of the inertial type, such asvertical vane, coalescing elements, a low velocity plenum, or a moistureseparator known to those skilled in the art. The gas turbine air inletmay include filtration elements, such as air filters 541, that may belocated either upstream or downstream or both up and downstream of theair chillers or coolers 557, 558 and the separators 601, 602,respectively. Preferably, at least one filtration element is locatedupstream of the chiller(s) and separator(s). This air filtration elementmay include a moisture barrier, such as an ePTFE (expanded PTFE)membrane which may be sold under the GORETEX trademark, to removeatmospheric mist, dust, salts or other contaminants that may beconcentrated in the condensed water removed by separators 601, 602. Bylocating at least one filtration element or similar device upstream ofthe chiller and separator associated with gas turbines 524 and/or 538atmospheric contaminants in the collected moisture (water) can beminimized, fouling and corrosion of the chiller(s) and separator(s) canbe minimized, and fouling and corrosion of the wet air fin cooler 604can also be controlled and minimized.

During the chilling of the gas turbine inlet air 570, 571, a significantportion of the refrigeration duty is used to condense the moisture inthe gas turbine inlet air 570, 571 rather than simply reducing the drybulb temperature of the inlet air. As an example, if inlet air with adry bulb temperature of 40° Celsius and a wet bulb temperature of 24°Celsius is chilled, the effective specific heat of the air is about 1kJ/kg/° C. between 40° C. and 24° C. but increases dramatically to about3 kJ/kg/° C. below the wet bulb temperature of 24° C. as the dry bulbtemperature is reduced and moisture is condensed from the air. Fromthis, one could conclude that about two-thirds of the refrigeration dutyused to chill the air below the wet bulb temperature (dew point) iswasted since the small compositional change of the air to the gasturbine 524 and/or 538 has only a small effect on the available power ofthe gas turbine. This condensed moisture is essentially at the sametemperature as the chilled inlet air to the gas turbine and could beused to provide some precooling of the inlet air 570, 571 using anotherchilling coil similar to air chillers or coolers 557 or 558 that ispositioned ahead of the air chillers or coolers 557 or 558 in the airflow. However, this arrangement can only recoup the part of therefrigeration duty used to reduce the temperature of the water but notthe part used to condense it. That is, the heat of vaporization of thewater cannot be recouped by heat transfer or psychometric cooling withthe gas turbine inlet air.

A much greater portion of the refrigeration duty used to cool andcondense the moisture from the gas turbine inlet air 570, 571 can berecouped by collecting this chilled water from separators 601 or 602,pumping it with a pump 603 and spraying the water onto the tubes of thewet air fin cooler 604 or otherwise mixing the water with the air flow606 to the wet air fin cooler 604. Based on the ambient conditions andthe actual flow rate of air conveyed by the fan associated with the wetair fin cooler 604, the water pumped by pump 603 may be sufficient tosaturate the air flow of wet air tin cooler 604 and bring it to its wetbulb temperature. Excess water flow from separators 601, 602 may beavailable that could be used for another purpose, or may beinsufficient, to saturate the air flow. In this later case, additionalwater from another source may be provided.

The disclosed aspects may be varied in many ways. For example, FIG. 7depicts a refrigeration compression string 700 that may be part of anLNG train according to disclosed aspects, in which an independentcooling mechanical refrigeration system 702 chills the inlet air of thelarge scale multi-shaft gas turbine 704. As with the inlet air coolingsystem disclosed in FIGS. 5 and 6 , such inlet air cooling or chillingboosts power available to the refrigeration compression string 700,thereby likely exceeding single train capacities of 9 MTA. FIG. 8depicts another refrigeration compression string 800 that may be part ofan LNG train according to disclosed aspects, in which a large scalemulti-shaft gas turbine 802 is equipped with a waste heat recovery unit804, according to known principles, which extracts heat from the hotexhaust gases of the turbine, thereby increasing overall energyefficiency of the LNG train. The inputs and outputs of the waste heatrecovery unit are not shown in FIG. 8 so that any such waste heatrecovery unit is represented thereby. FIG. 9 depicts anotherrefrigeration compression string 900 that may be part of an LNG trainaccording to disclosed aspects, in which an electrical generator 902 isincluded as part of the refrigeration compression string. The electricalgenerator 902 converts excess mechanical power of the large scalemulti-shaft gas turbine 904 into electricity and exports the electricityto an electrical grid (not shown). Any of the aspects disclosed in FIGS.7-9 may be implemented in one, two, or three of the refrigerationcompression strings of the LNG train 400 depicted in FIG. 4 . Moreover,it is contemplated that features from various examples described hereincan be combined together, including some but not necessarily all thefeatures provided for given examples. Furthermore, the features of anyparticular example are not necessarily required to implement the presenttechnological advancement.

FIG. 10 is a method 1000 of producing liquefied natural gas (LNG)according to aspects of the disclosure. At block 1002 each of first,second, and third refrigeration compression strings are arranged toinclude one or more refrigeration compressors and a multi-shaft gasturbine operationally connected to the one or more refrigerationcompressors. At block 1004, using the multi-shaft gas turbine in each ofthe first, second, and third refrigeration compression strings, therespective one or more refrigeration compressors are driven using anon-synchronous operation. At block 1006, without assistance fromelectrical motors with drive-through capability or variable frequencydrives, an inherent speed turn-down range of at least one of themulti-shaft gas turbines of the first, second, and third refrigerationcompression strings is used to start the one or more refrigerationcompressors from rest (either with refrigerant compression remaining inthe refrigeration compression loop or without such compression), bringthe one or more refrigeration compressors up to an operating rotationalspeed, and adjust compressor operating points to maximize efficiency ofthe one or more refrigeration compressors.

The disclosed aspects provide a method of producing LNG using two ormore compression strings without the need for expensive start-up motorsor variable speed drives. An advantage of the disclosed aspects isreduced capital expense for a large-scale LNG train (i.e., greater than7 MTA). Another advantage is a reduced areal footprint of a large-scaleLNG train. Still another advantage is that the LNG train may be coupledwith other technologies (such as inlet air cooling or exhaust heatrecovery) to improve efficiencies of the LNG train.

Aspects of the disclosure may include any combinations of the methodsand systems shown in the following numbered paragraphs. This is not tobe considered a complete listing of all possible aspects, as any numberof variations can be envisioned from the description above.

1. A drive system for liquefied natural gas (LNG) refrigerationcompressors in a LNG liquefaction plant, comprising:

first, second, and third refrigeration compression strings, eachrefrigeration compression string including

-   -   one or more refrigeration compressors, and    -   a multi-shaft gas turbine capable of non-synchronous operation,        the multi-shaft gas turbine being operationally connected to the        one or more refrigeration compressors and configured to drive        the one or more refrigeration compressors, wherein the        multi-shaft gas turbine uses its inherent speed turndown range        to        -   start the one or more refrigeration compressors from rest,        -   bring the one or more refrigeration compressors up to an            operating rotational speed, and        -   adjust compressor operating points to maximize efficiency of            the one or more refrigeration compressors,        -   without assistance from electrical motors with drive-through            capability and variable frequency drives;

wherein the first refrigeration compression string is configured toprovide compression to a propane refrigerant, the second refrigerationcompression string is configured to provide compression to a mixedrefrigerant, and the third refrigeration compression string isconfigured to provide compression to a nitrogen refrigerant.

2. The drive system of paragraph 1, further comprising a waste heatrecovery unit that extracts heat from exhaust gases of the multi-shaftgas turbine of at least one of the first, second, and thirdrefrigeration compression strings, thereby increasing overall energyefficiency of the LNG liquefaction plant.3. The drive system of paragraph 1 or paragraph 2, further comprising aninlet air chilling apparatus configured to chill air entering an inletof the multi-shaft gas turbine of at least one of the first, second, andthird refrigeration compression strings, thereby maximizing natural gasthroughput and/or efficiency of the LNG liquefaction plant.4. The drive system of paragraph 3, wherein the inlet air chillingapparatus comprises a mechanical refrigeration system that isindependent of the first, second, or third refrigeration compressionstrings.5. The drive system of paragraph 3, wherein the inlet air chillingapparatus comprises a mechanical refrigeration system that is integratedwith at least one of the first, second, or third refrigerationcompression strings, wherein the air entering the inlet of themulti-shaft gas turbine of at least one of the first, second, and thirdrefrigeration compression strings is chilled using refrigerantcompressed by one or more of the refrigeration compressors of the first,second, or third compression strings.6. The drive system of any of paragraphs 1-5, wherein operation of allof the multi-shaft gas turbines of the first, second, and thirdrefrigeration compression strings is required for natural gasliquefaction.7. The drive system of any of paragraphs 1-5, wherein operation of onlytwo of the multi-shaft gas turbines of the first, second, and thirdrefrigeration compression strings is required for natural gasliquefaction.8. The drive system of paragraph 7, wherein the first refrigerationcompression string is further configured to provide compression to amixed refrigerant, the second refrigeration compression string isfurther configured to provide compression to the propane refrigerant,and wherein operation of

only one of the multi-shaft gas turbines of the first refrigerationcompression string and the second refrigeration compression string, and

the multi-shaft gas turbine of the third refrigeration compressionstring, is required for natural gas liquefaction.

9. The drive system of any of paragraphs 1-5, wherein the firstrefrigeration compression string is further configured to providecompression to the mixed refrigerant, the second refrigerationcompression string is further configured to provide compression to thepropane refrigerant, and wherein operation of only one of themulti-shaft gas turbines of the first, second, and third refrigerationcompression strings is required for natural gas liquefaction.10. The drive system of any of paragraphs 1-9, wherein a refrigerantcompressed by at least one of the refrigeration compressors of at leastone of the first, second, or third refrigeration compression strings iscooled by air.11. The drive system of any of paragraphs 1-10, wherein a refrigerantcompressed by at least one of the refrigeration compressors of at leastone of the first, second, or third refrigeration compression strings iscooled by water.12. The drive system of any of paragraphs 1-11, wherein at least one ofthe first, second, and third refrigeration compression strings includesan electrical generator that converts excess turbine mechanical power toelectricity and exports the electricity to an electrical grid.13. The drive system of any of paragraphs 1-12, wherein each multi-shaftgas turbine of the first, second, and third refrigeration compressionstrings has a rated output capacity of at least 70 megawatts.14. The drive system of paragraph 1, wherein one or more refrigerationcompressors of one of the first, second, and third compression stringsassists compression work of another of the first, second, and thirdcompression strings.15. A method of producing liquefied natural gas (LNG), comprising:

arranging each of first, second, and third refrigeration compressionstrings to include one or more refrigeration compressors and amulti-shaft gas turbine operationally connected to the one or morerefrigeration compressors;

using the multi-shaft gas turbine in each of the first, second, andthird refrigeration compression strings, driving the respective one ormore refrigeration compressors using a non-synchronous operation;

providing compression to a propane refrigerant using the firstrefrigeration compression string;

providing compression to a mixed refrigerant using the secondrefrigeration compression string;

providing compression to a nitrogen refrigerant using the thirdrefrigeration compression string;

without assistance from electrical motors with drive-through capabilityor variable frequency drives, using an inherent speed turn-down range ofat least one of the multi-shaft gas turbines of the first, second, andthird refrigeration compression strings to

-   -   start the one or more refrigeration compressors from rest,    -   bring the one or more refrigeration compressors up to an        operating rotational speed, and    -   adjust compressor operating points to maximize efficiency of the        one or more refrigeration compressors.        16. The method of paragraph 15, further comprising:

extracting heat from exhaust gases of the multi-shaft gas turbine of atleast one of the first, second, and third refrigeration compressionstrings using a waste heat recovery unit.

17. The method of paragraph 15 or paragraph 16, further comprising:

chilling air entering an inlet of the multi-shaft gas turbine of atleast one of the first, second, and third refrigeration compressionstrings.

18. The method of paragraph 17, wherein the inlet air chilling apparatuscomprises a mechanical refrigeration system that is independent of thefirst, second, or third refrigeration compression strings.

19. The method of paragraph 17, wherein chilling the air comprises:

chilling the air entering the inlet of the multi-shaft gas turbine of atleast one of the first, second, and third refrigeration compressionstrings using refrigerant compressed by one or more of the refrigerationcompressors of the first, second, or third compression strings.

20. The method of any of paragraphs 15-20, wherein operation of all ofthe multi-shaft gas turbines of the first, second, and thirdrefrigeration compression strings is required for natural gasliquefaction.

21. The method of any of paragraphs 15-19, wherein operation of only twoof the multi-shaft gas turbines of the first, second, and thirdrefrigeration compression strings is required for natural gasliquefaction.

22. The method of paragraph 21, further comprising:

providing compression to the propane refrigerant and the mixedrefrigerant using the first refrigeration compression string; and

providing compression to the propane refrigerant and the mixedrefrigerant using the second refrigeration compression string;

wherein operation of only one of

-   -   the multi-shaft gas turbines of the first refrigeration        compression string and the second refrigeration compression        string, and    -   the multi-shaft gas turbine of the third refrigeration        compression string, is required for natural gas liquefaction.        23. The method of any of paragraphs 15-19, further comprising:

providing compression to the propane refrigerant and the mixedrefrigerant using the first refrigeration compression string; and

providing compression to the propane refrigerant and the mixedrefrigerant using the second refrigeration compression string;

wherein operation of only one of the multi-shaft gas turbines of thefirst, second, and third refrigeration compression strings is requiredfor natural gas liquefaction.

24. The method of any of paragraphs 15-23, further comprising:

air-cooling a refrigerant compressed by at least one of therefrigeration compressors of at least one of the first, second, or thirdrefrigeration compression strings.

25. The method of any of paragraphs 1-24, further comprising:

water-cooling a refrigerant compressed by at least one of therefrigeration compressors of at least one of the first, second, or thirdrefrigeration compression strings.

26. The method of any of paragraphs 15-25, further comprising:

converting excess turbine electrical power of the multi-shaft gasturbine of at least one of the first, second, and third refrigerationcompression strings into electricity using an electrical generator; and

exporting the electricity to an electrical grid.

27. The method of any of paragraphs 15-26, further comprising:

-   -   moving one or more compression stages of a refrigeration        compressor in one of the first, second, or third compression        strings, to another of the first, second, or third compression        strings, to thereby assist compression work of the one of the        first, second, or third compression strings.

While the present techniques can be susceptible to various modificationsand alternative forms, the examples described above are non-limiting. Itshould again be understood that the techniques is not intended to belimited to the particular embodiments disclosed herein. Indeed, thepresent techniques include all alternatives, modifications, andequivalents falling within the true spirit and scope of the appendedclaims.

What is claimed is:
 1. A method of producing liquefied natural gas (LNG)in a LNG liquefaction plant, comprising: arranging each of first,second, and third refrigeration compression strings to include one ormore refrigeration compressors and a multi-shaft gas turbineoperationally connected to the one or more refrigeration compressors;using the multi-shaft gas turbine in each of the first, second, andthird refrigeration compression strings, driving the respective one ormore refrigeration compressors at an operating rotational speed that isnot always aligned with the frequency of an electrical grid of the LNGliquefaction plant; providing compression to a propane refrigerant andto a mixed refrigerant using the first refrigeration compression string;providing compression to the propane refrigerant and the mixedrefrigerant using the second refrigeration compression string; providingcompression to a nitrogen refrigerant using the third refrigerationcompression string; and without assistance from electrical motors withdrive-through capability or variable frequency drives, using an inherentspeed turn-down range of the multi-shaft gas turbine of at least one ofthe first, second, and third refrigeration compression strings to startthe one or more refrigeration compressors from rest, bring the one ormore refrigeration compressors up to an initial operating rotationalspeed, and adjust compressor operating points to maximize efficiency ofthe one or more refrigeration compressors; and wherein operation of themulti-shaft gas turbine of only one of the first, second, and thirdrefrigeration compression strings is required for natural gasliquefaction, wherein each multi-shaft gas turbine of the first, second,and third refrigeration compression strings has a rated output capacityof at least 70 megawatts.
 2. The method of claim 1, further comprising:extracting heat from exhaust gases of the multi-shaft gas turbine of atleast one of the first, second, and third refrigeration compressionstrings using a waste heat recovery unit.
 3. The method of claim 1,further comprising: using an inlet air chilling apparatus, chilling airentering an inlet of the multi-shaft gas turbine of at least one of thefirst, second, and third refrigeration compression strings.
 4. Themethod of claim 3, wherein the inlet air chilling apparatus comprises amechanical refrigeration system that is independent of the first,second, or third refrigeration compression strings.
 5. The method ofclaim 3, wherein chilling the air comprises: chilling the air enteringthe inlet of the multi-shaft gas turbine of at least one of the first,second, and third refrigeration compression strings using refrigerantcompressed by one or more of the refrigeration compressors of the first,second, or third compression strings.
 6. The method of claim 1, furthercomprising: air-cooling a refrigerant compressed by at least one of therefrigeration compressors of at least one of the first, second, or thirdrefrigeration compression strings.
 7. The method of claim 1, furthercomprising: water-cooling a refrigerant compressed by at least one ofthe refrigeration compressors of at least one of the first, second, orthird refrigeration compression strings.
 8. The method of claim 1,further comprising: converting excess turbine electrical power of themulti-shaft gas turbine of at least one of the first, second, and thirdrefrigeration compression strings into electricity using an electricalgenerator; and exporting the electricity to an electrical grid.